U.S. patent number 7,428,932 [Application Number 11/766,085] was granted by the patent office on 2008-09-30 for completion system for a well.
This patent grant is currently assigned to PetroQuip Energy Services, LLP. Invention is credited to Michael Chad Darby, William John Darnell, William Ryle Darnell, Rodney Wayne Long, Charles David Wintill.
United States Patent |
7,428,932 |
Wintill , et al. |
September 30, 2008 |
Completion system for a well
Abstract
A completion system for a well including an upper production
tubing disposed within a wellbore. An upper packer engaging the
upper production tubing a top pin connector with seal assembly
engaging the upper packer. A first intermediate production tubing
disposed between the top pin connector with seal assembly and a top
hydraulically operated tool.
Inventors: |
Wintill; Charles David
(Houston, TX), Long; Rodney Wayne (Cypress, TX), Darnell;
William Ryle (St. Martinville, LA), Darnell; William
John (Houston, TX), Darby; Michael Chad (Katy, TX) |
Assignee: |
PetroQuip Energy Services, LLP
(Houston, TX)
|
Family
ID: |
39776450 |
Appl.
No.: |
11/766,085 |
Filed: |
June 20, 2007 |
Current U.S.
Class: |
166/381;
166/242.6; 166/380; 166/387 |
Current CPC
Class: |
E21B
17/18 (20130101); E21B 33/124 (20130101); E21B
23/04 (20130101) |
Current International
Class: |
E21B
23/00 (20060101) |
Field of
Search: |
;166/380,381,51,387,242.6 |
References Cited
[Referenced By]
U.S. Patent Documents
Primary Examiner: Wright; Giovanna C
Attorney, Agent or Firm: Buskop Law Group, PC Buskop;
Wendy
Claims
What is claimed is:
1. A completion system for a well, comprising: upper production
tubing disposed within a wellbore; an upper packer engaging the
upper production tubing; a top pin connector with seal assembly
engaging the upper packer, wherein the top pin connector with seal
assembly comprises: a wet connect assembly, wherein the wet connect
assembly comprises: a lower tubular portion comprising: a lower
tubular body having a lower tubular body face; a first pin having a
first pin outer surface; and a lower hydraulic flow path formed in
the lower tubular portion; an extending hydraulic wet connector for
at least partially engaging the lower tubular portion; an upper
tubular portion removably connected to the lower tubular portion,
wherein the lower tubular portion comprises: an upper tubular body
for supporting a receiving hydraulic wet connector; and an
intermediate hydraulic flow path formed in the upper tubular body
fluidly engaging the lower hydraulic flow path; wherein the
receiving hydraulic wet connector engages the upper tubular portion
and removably engages the extending hydraulic wet connector; a seal
assembly removably engaging the upper tubular portion, wherein the
seal assembly comprises: a tubular seal assembly body; an upper
hydraulic flow path formed in the tubular seal assembly body
fluidly engaging the intermediate hydraulic flow path; and a
plurality of upper concentric seals forming a sealing engagement
around the upper hydraulic flow path seals; at least one fastener
disposed in: the lower tubular portion for latching the lower
tubular portion to the upper tubular portion; the upper tubular
portion for anchoring the upper tubular portion to another piece of
well equipment; and the seal assembly for anchoring the seal
assembly to another piece of well equipment or combinations
thereof; a first intermediate production tubing disposed between
the top pin connector with seal assembly and a top hydraulically
operated tool; a first control line is secured to a power source
and the upper tubular portion of the top pin connector with seal
assembly; a second control line is in communication with the lower
tubular portion of the top pin connector with seal assembly and the
top hydraulically operated tool; a second intermediate production
tubing is disposed between the top hydraulically operated tool and
an intermediate packer; a third control line is in fluid
communication between the top hydraulically operated tool and an
upper tubular portion of an intermediate pin connector with seal
assembly engaging the intermediate packer; a fourth control line is
in fluid communication between a lower tubular portion of the
intermediate pin connector with seal assembly and a bottom
hydraulically operated tool; a first bottom production tubing is
disposed between the intermediate pin connector with seal assembly
and the bottom hydraulically operated tool; and a second bottom
production tubing is disposed between the bottom hydraulically
operated tool and a lower sealing means.
2. The system of claim 1, wherein the system of claim 1 is
repeatable to accommodate additional wellbore zones.
3. The system of claim 1, wherein each upper tubular portion
comprises an upper portion of a locking mechanism connected to each
upper tubular body engaging a locking mechanism on each lower
tubular body.
4. The system of claim 3, wherein each locking mechanism on each
lower tubular body is a collar.
5. The system claim 4, further comprising a lower tubular seal
disposed between each collar and each lower tubular portion.
6. The system of claim 4, wherein each collar is disposed around
each lower tubular portion.
7. The system of claim 3, wherein the upper portion of each locking
mechanism comprises: a locking key; a lower key retainer; a shear
pin for engaging the locking key and the lower key retainer; an
upper key retainer for engaging the locking key and the upper
tubular portion; at least one fastener; and a mechanism for
exerting a force on the locking key and the upper tubular
portion.
8. The system of claim 1, further comprising at least one alignment
key at least partially disposed on each lower tubular portion.
9. The system of claim 8, wherein each upper tubular portion
comprises at least one alignment groove formed on each upper
tubular body for receiving the at least one alignment key.
10. The system of claim 8, wherein each at least one fastener
disposed in each lower tubular portion is for anchoring each lower
tubular portion to another piece of well equipment.
11. The system of claim 8, wherein each alignment key is disposed
on an inner diameter of each tubular body and extending from a top
portion of each tubular body no more than 10% of the length of each
tubular body.
12. The system of claim 1, further comprising a plurality of upper
hydraulic flow path seals between the tubular seal assembly body
and each upper tubular body.
13. The system of claim 1, further comprising a plurality of seal
assembly fasteners for applying a force to each of the upper
hydraulic flow path seals forming a sealing engagement in each
upper hydraulic flow path.
14. The system of claim 1, wherein each upper portion is threaded
to each lower portion.
15. The system of claim 1, wherein each receiving hydraulic wet
connector is a quick release.
16. The system of claim 1, wherein each of the hydraulic flow path
seals are non-elastomeric.
17. The system of claim 1, wherein each of the hydraulic flow path
seals have different diameters.
18. The system of claim 1, further comprising a second pin
surrounding the first pin in each lower tubular portion forming a
double pin connector, and wherein each double pin connector is
adapted for multi zone gravel packing in a well.
19. The system of claim 1, further comprising a control line
connector disposed between each first pin outer surface and each
lower tubular body face.
20. The system of claim 1, wherein each seal assembly has a
hydraulic flow path plug for providing a sealing engagement with
each upper hydraulic flow path and each tubular seal assembly
body.
21. The system of claim 1, further comprising at least one seal
ring for supporting each at least one upper hydraulic flow path
seal.
22. A completion system for a gravel pack well comprising: an upper
production tubing disposed within a wellbore; an upper gravel
packer engaging the upper production tubing; a top pin connector
with seal assembly engaging the upper gravel packer, wherein the
top pin connector with seal assembly comprises: a wet connect
assembly, wherein the wet connect assembly comprises: a lower
tubular portion comprising: a lower tubular body having a lower
tubular body face; a first pin having a first pin outer surface; a
second pin surrounding the first pin; and a lower hydraulic flow
path formed in the lower tubular portion; an extending hydraulic
wet connector for at least partially engaging the lower tubular
portion; an upper tubular portion removably connected to the lower
tubular portion, wherein the lower tubular portion comprises: an
upper tubular body for supporting a receiving hydraulic wet
connector; an intermediate hydraulic flow path formed in the upper
tubular body fluidly engaging the lower hydraulic flow path; and
wherein the receiving hydraulic wet connector is for engaging the
upper tubular portion and removably engaging the extending
hydraulic wet connector; a seal assembly removably engaging the
upper tubular portion, wherein the seal assembly comprises: a
tubular seal assembly body; an upper hydraulic flow path formed in
the tubular seal assembly body fluidly engaging the intermediate
hydraulic flow path; and a plurality of upper concentric seals
forming a sealing engagement around the upper hydraulic flow path
seals; and at least one fastener disposed in: the lower tubular
portion for latching the lower tubular portion to the upper tubular
portion; the upper tubular portion for anchoring the upper tubular
portion to another piece of well equipment; and the seal assembly
for anchoring the seal assembly to another piece of well equipment
or combinations thereof; wherein the lower tubular portion of the
top pin connector with seal assembly is connected to a top external
blank pipe and a top internal blank pipe; wherein: the upper
tubular portion of the top pin connector is in fluid communication
with a first control line secured to a power source; a top
hydraulically operated tool is connected to the top external blank
pipe and is in fluid communication with a second control line in
fluid communication with the lower tubular portion of the top pin
connector for periodically controlling the top hydraulically
operated tool; a top well screen is secured to the top external
blank pipe; and a top external seal assembly engages an
intermediate gravel packer and a bottom of the top well screen; a
first intermediate blank pipe is connected to the top hydraulically
operated tool and the upper tubular portion of an intermediate pin
connector with seal assembly engaging the intermediate packer; a
third control line is in fluid communication the top hydraulically
operated tool and the upper tubular portion of the intermediate pin
connector with seal assembly; the lower tubular portion of the
intermediate pin connector with seal assembly is connected to a
first intermediate external blank pipe and a second intermediate
internal blank pipe is connected to a bottom hydraulically operated
tool; a bottom internal blank pipe is connected to the bottom
hydraulically operated tool and a bottom isolation seal assembly; a
fourth control line is in fluid communication with the lower
tubular portion of the intermediate pin connector and the bottom
hydraulically operated tool; a lower well screen is secured to the
first intermediate external blank pipe; and a seal assembly with a
polished bore is secured to the lower well screen and secured to a
lower sealing means.
23. The system of claim 22, wherein the system of claim 22 is
repeatable to accommodate additional wellbore zones.
24. The system of claim 22, wherein each upper tubular portion
comprises an upper portion of a locking mechanism connected to each
upper tubular body engaging a locking mechanism on each lower
tubular body.
25. The system of claim 24, wherein each locking mechanism on each
lower tubular body is a collar.
26. The system claim 25, further comprising a lower tubular seal
disposed between each collar and each lower tubular portion.
27. The system of claim 26, wherein each collar is disposed around
each lower tubular portion.
28. The system of claim 24, wherein the upper portion of each
locking mechanism comprises: a locking key; a lower key retainer; a
shear pin for engaging the locking key and the lower key retainer;
an upper key retainer for engaging the locking key and the upper
tubular portion; at least one fastener; and a mechanism for
exerting a force on the locking key and the upper tubular
portion.
29. The system of claim 22, further comprising at least one
alignment key at least partially disposed on each lower tubular
portion.
30. The system of claim 29, wherein each upper tubular portion
comprises at least one alignment groove formed on each upper
tubular body for receiving the at least one alignment key.
31. The system of claim 29, wherein each alignment key is disposed
on an inner diameter of each tubular body and extending from a top
portion of each tubular body no more than 10% of the length of each
tubular body.
32. The system of claim 22, further comprising a plurality of upper
hydraulic flow path seals between the tubular seal assembly body
and each upper tubular body.
33. The system of claim 22, wherein each at least one fastener
disposed in each lower tubular portion is for anchoring each lower
tubular portion to another piece of well equipment.
34. The system of claim 22, further comprising a plurality of seal
assembly fasteners for applying a force to each of the upper
hydraulic flow path seals forming a sealing engagement in each
upper hydraulic flow path.
35. The system of claim 22, wherein each upper portion is threaded
to each lower portion.
36. The system of claim 22, wherein each receiving hydraulic wet
connector is a quick release.
37. The system of claim 22, wherein each of the hydraulic flow path
seals are non-elastomeric.
38. The system of claim 22, wherein each of the hydraulic flow path
seals have different diameters.
39. The system of claim 22, further comprising a control line
connector disposed between each first pin outer surface and each
lower tubular body face.
40. The system of claim 22, wherein each seal assembly has a
hydraulic flow path plug for providing a sealing engagement with
each upper hydraulic flow path and each tubular seal assembly
body.
41. The system of claim 22, further comprising at least one seal
ring for supporting each at least one upper hydraulic flow path
seal.
Description
FIELD
The present embodiments relate generally to a completion system for
a well.
BACKGROUND
A need exists for an intelligent completion system for use inside a
multi-zone hydrocarbon well.
There further exists a need for a completion system that uses a pin
connector with seal assembly that can be pulled after use, taken
apart, cleaned, and reused.
The present embodiments meet these needs.
BRIEF DESCRIPTION OF THE DRAWINGS
The detailed description will be better understood in conjunction
with the accompanying drawings as follows:
FIG. 1 depicts a cross sectional view of an embodiment of a seal
assembly usable with the well completion system.
FIG. 2 depicts a cross sectional view of an embodiment of an upper
tubular portion for an embodiment of the well completion
system.
FIG. 3 depicts a detailed cross sectional view of a locking
mechanism for use with the well completion system.
FIG. 4a depicts a cross sectional view of an embodiment of an upper
tubular body with at least one alignment groove that is usable with
the embodiments of well completion system.
FIG. 4b is a perspective view of the upper tubular body with the
alignment groove usable with the well completion system.
FIG. 5 depicts a cross sectional view of an embodiment of a lower
tubular portion for an embodiment of the pin connector with seal
assembly.
FIG. 6A depicts a flow diagram for a method for installing an
embodiment of the well completion system.
FIG. 6B is a continuation of the flow diagram for the method for
installing an embodiment of the well completion system.
FIG. 7 depicts an embodiment of an assembled well completion
system.
FIG. 8 depicts an embodiment of an assembled well completion system
adapted for use with a gravel pack.
The present embodiments are detailed below with reference to the
listed Figures.
DETAILED DESCRIPTION OF THE EMBODIMENTS
Before explaining the present embodiments in detail, it is to be
understood that the embodiments are not limited to the particular
embodiments and that they can be practiced or carried out in
various ways.
The embodiments of the invention generally relate to a completion
system for a well.
A first embodiment of the well completion system can include an
upper production tubing disposed with in a wellbore. An upper
packer can engage the upper production tubing. A top pin connector
with seal assembly can engage the upper packer.
The pin connector can be formed from a tubular having an upper
tubular portion and a lower tubular portion.
The lower tubular portion has an upper tubular body and a lower
tubular body with a lower tubular body face.
A first pin engages the wet connect assembly. The first pin has a
first pin outer surface, which can be connected to the wet connect
assembly.
In a second embodiment, a double pin is in the lower tubular
portion. The double pin engages the wet connect assembly. In the
double pin embodiment, a second pin concentrically surrounds the
first pin forming a double pin connector. The double pin connector
is particularly useful in packers such as those adapted for multi
zone gravel packing in hydrocarbon wells.
In either the single pin or double pin version of the pin connector
with seal assembly, a control line connector, such as a jam nut, is
used on the first pin outer surface and the lower tubular body
face.
At least one alignment key is formed in at least a part of the
tubular body. The alignment key can be disposed on an inner
diameter of the tubular body and can extend from a top portion of
the lower tubular body toward a mid section of the lower tubular
body. The alignment key, in an embodiment, is formed at an angle
from the top, sloping in a curve, such as a sine curve along the
lower tubular body. The alignment key extends no more than 10% the
length of the lower tubular body.
In an alternative embodiment of the pin connector with seal
assembly, the at least one alignment key can be disposed on an
interior wall of the tubular body portion. Multiple alignment keys
can be used on one tubular body portion for a secure locking
engagement.
The lower tubular body has a lower hydraulic flow path formed
within the lower tubular body for flowing controlled hydraulic
fluids. This lower hydraulic flow path communicates on one end with
a hydraulic wet connector.
Additionally, a two part locking mechanism can be used to connect
the upper tubular portion to the lower tubular portion. In an
embodiment, one part of the locking mechanism has a collar. The
collar can be threaded or force fit to the second part of the
locking mechanism. Additionally, a lower tubular seal can be
disposed between the collar and the lower tubular portion to ensure
a snug, leak-tight fit.
The two part locking mechanism can be used to secure the upper
tubular portion or the seal assembly to another piece of well
equipment.
The second part of the locking mechanism is a locking key. The
locking key is engaged by a shear pin. The shear pin further
engages a lower key retainer. The locking key is also engaged using
an upper key retainer. The upper key retainer engages the upper
tubular portion. The upper portion of the locking mechanism has at
least one fastener, such as a screw, to secure the upper portion of
the locking mechanism. A force is exerted on the upper tubular
portion and the locking key by a mechanism, such as a coiled
spring, a wave spring, or similar force applying mechanism.
The upper tubular portion is removeably connected to the lower
tubular portion, such as with force fit connection or stabbed in
connection. It is also contemplated that the upper tubular portion
can be stabbed into the lower tubular portion for a secure
connection, such as a body lock ring.
The upper tubular portion has a receiving hydraulic wet connector,
which removably engages the extending hydraulic wet connector of
the lower tubular portion.
In an embodiment, the receiving hydraulic wet connector is a quick
release hydraulic wet connector, which is particularly useful in an
emergency, such as when there is an excessive pressure build up and
there is a need for a fast release.
An intermediate hydraulic flow path is also formed in the upper
tubular body. The intermediate hydraulic flow path fluidly engages
the lower hydraulic flow path.
At least one alignment groove is formed on the upper tubular body.
The alignment groove is for receiving at least one alignment key.
At least one alignment key is formed in the upper tubular body, and
an alignment groove is formed in the lower tubular portion for
receiving the at least one alignment key.
In the present embodiment of the pin connector with seal assembly,
the upper tubular portion removably engages a seal assembly. The
seal assembly can include a tubular seal assembly body. In the
tubular seal assembly an upper hydraulic flow path can be formed
which fluidly engages the intermediate hydraulic flow path.
Between the tubular seal assembly body and the upper tubular body
there can be a plurality of upper hydraulic flow path seals. The
hydraulic flow path seals are contemplated to be non-elastomeric,
such as metal to metal seals. The hydraulic flow path seals can
have different diameters from each other. In another embodiment,
the hydraulic flow path seals are all the same diameter.
A plurality of upper concentric seals can be positioned, such that
they form a sealing engagement around the upper hydraulic flow path
seals. A sealing engagement can be formed in the upper hydraulic
flow path by using a plurality of seal assembly fasteners to apply
a force to the upper hydraulic flow path seals. An example of a
seal assembly fastener is a snap ring. The seal assembly fasteners
can be made from any alloy steel readily available from Smalley
Spring Company, Chicago, Ill.
In an embodiment at least one seal ring can be used for supporting,
such as rigidly supporting, at least one upper hydraulic flow path
seal. The seal ring can be made from a plastic or alloy steel.
A hydraulic flow path plug can be used to provide a sealing
engagement with the upper hydraulic flow path and the tubular seal
assembly body. The plug can have a diameter of between 0.032 inches
and 0.500, and a length of between 0.125 and 0.562.
The pin connector with seal assembly can be used within a packer to
form an integrated wet connect assembly. The integrated wet connect
assembly preferably engages a valve and production tubing on one
end and another seal assembly on the other end of the integrated
wet connect assembly.
The embodiments of the pin connector with seal assembly reduce
installation time and the costs associated with downhole
hydrocarbon production.
An embodiment of the pin connector with seal assembly provides
downhole well equipment that is more efficient because there is no
field assembly required.
An embodiment of the pin connector with seal assembly can be
assembled at a remote location, and can be ready for immediate use
upon reaching the field.
An embodiment of the pin connector with seal assembly is a well
containment feature because the downhole assembly is stung in or
engaging the well. Thereby, isolating the well and preventing well
bore fluid from leaking into the annulus above the packer,
preventing a well control situation. The seal assembly prevents
fluid from leaking into the environment and contaminating water
tables.
The present embodiment of the well completion system can include a
first intermediate production tubing engaging the top pin connector
with seal assembly and a top hydraulically operated tool. A top
control line can be secured to a power source and the top pin
connector with seal assembly.
The first intermediate production tubing intermediate can be
secured to a bottom pin connector with seal assembly and the top
hydraulically operated tool.
A second intermediate production tubing is disposed between the top
hydraulically operated tool and an intermediate packer. A third
control line can be in fluid communication with the top
hydraulically operated tool and an upper tubular portion of an
intermediate pin connector with seal assembly. The intermediate pin
connector with seal assembly engages the intermediate packer.
A fourth control line is secured to the lower tubular portion of
the intermediate pin connector and the bottom hydraulically
operated tool.
In the present embodiment of the completion system for a well a
first bottom production tubing can engage the bottom hydraulic
operated tool and the intermediate pin connector with seal
assembly.
A second bottom production tubing engages the bottom hydraulically
operated tool and a lower sealing means.
It is contemplated that the present embodiment of the invention can
be adapted to accommodate a well having more zones by placing a
plurality of pin connectors with seal assemblies between the top
pin connector with seal assembly and the bottom pin connector with
seal assembly.
In a second embodiment of the completion system for a well the
completion system can be adapted for use with a gravel pack.
The completion system for the gravel pack well can include an upper
production tubing engaging an upper packer. An upper pin connector
with seal assembly can engage the upper packer.
In the present embodiment the pin connectors with seal assembly are
adapted for use with the gravel pack by having a second pin the
concentrically surrounds the first pin.
In the present embodiment of the well completion system for a
gravel pack well the upper tubular portion of the top pin connector
with seal assembly can be connected to the upper packer. A top
external blank pipe and a top internal blank pipe can also connect
to the lower tubular portion of the top pin connector with seal
assembly.
A first control line can be in communication with a power source
and a upper tubular portion of a top pin connector with seal
assembly. The lower portion of the top pin connector is secured to
a second control line.
A top hydraulically operated tool can be in communication with the
second control line. The second control line can periodically
control the top hydraulically operated tool. The top hydraulically
operated tool can be connected to the top external blank pipe.
A top well screen can be secured to the top external blank pipe. A
top external seal assembly can engage the top external blank pipe
and a top intermediate packer.
A first intermediate blank pipe is connected to the top
hydraulically operated tool. The upper tubular portion of an
intermediate pin connector with seal assembly can engage the
intermediate packer.
A third control line connects to the top hydraulically operated
tool and the upper tubular portion of the intermediate pin
connector with seal assembly.
The lower tubular portion of the intermediate pin connector with
seal assembly is connected to a first intermediate external blank
pipe and a second intermediate internal blank pipe connected to a
bottom hydraulically operated tool.
A bottom internal blank pipe connects to the bottom hydraulically
operated tool and a bottom isolation seal assembly.
A fourth control line can connect to the lower tubular portion of
the intermediate pin connector and the bottom hydraulically
operated tool.
A lower well screen is secured to the first intermediate external
blank pipe. A seal assembly with a polished bore is secured to the
lower well screen and secured within a lower sealing means.
In a contemplated embodiment the well completion system can be
adapted for use with a gravel pack well having an infinite number
of zones by disposing a plurality of pin connectors with seal
assembly between the top pin connector with seal assembly and the
bottom pin connector with seal assembly.
The embodiments of the invention can be best understood with
reference to the figures.
Referring now to FIG. 1, which depicts an embodiment of a seal
assembly 47. The seal assembly 47 includes a tubular seal assembly
body 4, a hydraulic flow path plug 6, an upper hydraulic flow path
10 formed in the tubular seal assembly body 4, a first seal ring
16a, a second seal ring 16b, and a third seal ring 16c, a first
upper hydraulic flow path seal 12a, a second hydraulic flow path
seal 12b, a first seal assembly fastener 14a, a second seal
assembly fastener 14b, a third seal assembly fastener 14c, a first
upper concentric seal 8a, a second upper concentric seal 8b, and a
third upper concentric seal 8c.
The tubular seal assembly body 4 can be made from alloy steel, and
can have a length ranging from 10 inches to 36 inches, a diameter
ranging from 2.688 inches to 6 inches. The seal assembly body 4 is
depicted having the hydraulic flow path plug 6, such as a lee plug
from Lee Company in Connecticut. The hydraulic flow path plug 6
provides a seal for the upper hydraulic flow path 10.
The hydraulic flow path can have a volumetric flow rate equivalent
to the capacity of a 0.25 inch control line. The hydraulic flow
path can be formed into the tubular seal assembly by inserting a
hydraulic line with a diameter ranging from 0.25 inches to 0.5
inches.
The first seal ring 16a can support a first hydraulic flow path
seal 12a and be made from an alloy steel or non elastomeric
material, such as a rigid polyethylene seal ring or rigid
polyethylene/polypropylene copolymers.
The second seal ring 16b can support the second hydraulic flow path
seal 12b. The first seal ring 16a and the second seal ring 16b
provide support to the hydraulic flow path seals 12a and 12b.
The first hydraulic flow path seal 12a and the second hydraulic
flow path seal 12b can be similar to each other or in the
alternative the first and second hydraulic flow path seals 12a and
12b can be different. The first and second hydraulic flow path
seals 12a and 12b can have a diameter ranging from 1.9 inches to
6.75 inches. The flow path seals can be made from non elastomeric
materials, such as polymer plastics, including poly ethyl ketone
(PEEK), or other materials.
The first seal ring 16a, the second seal ring 16b, and the third
seal ring 16c can be similar in design or in the alternative each
seal ring can be made from a different material. The diameters of
each seal ring can be similar or different.
The first seal assembly fastener 14a can be a threaded cap. The
second seal assembly fastener 14b, which can be similar to the
first seal assembly fastener 14a. The fasteners are adapted to
retain the second upper hydraulic flow path seal 12b.
The third seal assembly fastener 14c, which can be similar to the
second seal assembly fastener 14b, which can be similar to the
first seal assembly 14a.
It is possible to have an embodiment wherein the first seal
assembly fastener, the second seal ring fastener, the third seal
ring fastener can be made from steel.
The first, second and third concentric seals 8a, 8b, and 8c can be
an elastomeric or non-elastomeric seal. Greene Tweed from Houston
Tex. supplies usable concentric seals for this embodiment. The
first concentric seal 8a, the second concentric seal 8b, and the
third concentric seal 8c can be similar to each other.
Turning now to FIG. 2 the upper tubular portion 26 is depicted. The
upper tubular portion 26 has an upper tubular body 28 that
removably engages the seal assembly 47. The seal assembly 47 is
best depicted in FIG. 1. The upper tubular body 28 can be made from
alloy steel, and have a length ranging from 2 feet to 6 feet.
Returning to FIG. 2, the upper tubular portion 26 is depicted
having an intermediate hydraulic flow path 29. The intermediate
hydraulic flow path can have an inner diameter from 0.125 inches to
0.5 inches. In the alternative embodiment, the intermediate
hydraulic flow path can be a machined port. The intermediate
hydraulic flow path 29 is in fluid communication with the upper
hydraulic flow path 10. The upper hydraulic flow path 10 is
depicted in FIG. 1.
The intermediate hydraulic flow path 29 and the upper hydraulic
flow path 10 are coupled together, for example using the seals.
Referring now to FIG. 3, the upper tubular body 28 is connected to
an upper portion 30 of an exemplary locking mechanism. The upper
portion 30 is depicted having a shear pin 36, such as a brass or
annealed steel shear pin, such as those available from Shamrock
Fasteners of greater Houston, Tex.
A locking key 32 is machined as part of the overall pin and seal
assembly in to the upper tubular of the lower tubular portion or
both. The locking key is a combination of grooves and projections
that interlock together.
A lower key retainer 34 is a machined part used for holding the
locking key in either the locked or unlocked position. In an
embodiment, the lower key retainer can be a circular part with a
diameter larger than the annulus of the bore of the tool. The
retainer can be a segment, such as a "D" shape or an open "D"
shape.
An upper key retainer 38 can be similar to the lower key retainer.
In an embodiment, the upper key retainer can be a circular part
with a diameter larger than the annulus of the bore of the tool.
The upper key retainer can be a segment, such as a "D" shape or an
open "D" shape.
The mechanism for providing force 42 can be a coiled spring, a wave
spring, or a similar force providing mechanism. If a coiled spring
is used, it can be one provided by Suhm of Houston, Tex.
The shear pin 36 engages the locking key 32 and the lower key
retainer 34. The shear pin 36 can be a solid cylinder with a
centrally aligned through hole. The shear pin 36 can be made from
steel, stainless steel, or similar materials.
The upper key retainer 38 can have a channel, with a depth ranging
from 0.5 inches to 1 inches adapted for receiving the locking key
32.
The upper portion 30 is secured to upper tubular portion 26 by the
first fastener 40a and the second fastener 40b. The first fastener
40a and the second fastener 40b can be planarly aligned with each
other. It is possible to use more than two fasteners to secure the
upper locking mechanism to the upper tubular portion 26.
The mechanism for exerting force 42 interacts with the locking key
32 and the upper tubular portion 26.
The interaction of the mechanism for exerting force 42 with the
locking key 32 and the upper tubular portion 26 provides the
benefit of providing retraction in and out, an axial force when the
lower tubular portion is driven into the well, in a ratcheting
unidirectional motion.
Returning to FIG. 2, a fastener 23 can be located on the upper
tubular portion of the pin and seal assembly, for securing to a
piece of well equipment, wherein the piece of well equipment can be
a packer, or another type of well equipment.
The fastener 23 can be a collar for engaging a locking mechanism,
such as the upper portion 30 and anchoring the upper tubular
portion to another piece of well equipment.
FIG. 2 further depicts a lower tubular seal 25 which is disposed
between the collar 23 and the lower tubular portion 21. The lower
tubular seal 25 can have a diameter ranging from 1.9 inches to 6
inches. The lower tubular seal 25 can be made from plastic,
elastomeric material or a non-elastomeric material to create
seals.
The upper tubular portion has a receiving hydraulic wet connector
27, for example, a wet connect; such as a SEAPORT.TM. wet connects
made by Diamould from the United Kingdom; can be used. The
receiving hydraulic wet connector 27 removeably engages an
extending hydraulic wet connector 22, which can also be made by
Diamould. The receiving hydraulic wet connector 22 is supported by
the upper tubular body 28.
The upper tubular body 28 supports the receiving hydraulic wet
connector 22 by creating a threaded engagement with the receiving
hydraulic wet connector 22.
FIG. 2 depicts a first alignment key 19a, and a second alignment
key 19b, which is similar to the first alignment key 19a. The
alignment keys are machined parts that are at least partially
disposed on the lower tubular body 21.
Although the embodiment in FIG. 2 depicts two alignment keys, it is
possible to have more than two alignment keys or less than two
alignment keys, as long as there is at least one alignment key. In
an alternative embodiment, the alignment keys can differ from each
other. In length and thickness. For example one alignment key can
have a length of 1/4 inch and the second alignment key can have a
length of 10 inches.
Turning now to FIGS. 4a and 4b, which depict a first alignment
groove 44a and a second alignment groove 44b formed on the upper
tubular body 28. The first alignment groove 44a receives either
alignment key 19a and the second alignment groove 44b receives
either alignment key. There should be at least one alignment
groove.
The first alignment groove 44a and the second alignment groove 44b
can have a depth ranging from 0.30 inches to 0.05 inches. The
alignment grooves can be molded, machined, or forged into the upper
tubular body 28.
Turning now to FIG. 5, which depicts an embodiment of the lower
tubular portion 21. The lower tubular portion 21 has a lower
tubular body 15. The lower tubular body 15 can have a length
ranging from 2 feet to 6 feet, and an outer diameter ranging from 2
inches to 15 inches.
A lower hydraulic flow path 20 is formed into the lower tubular
body 15. The lower hydraulic flow path 20 fluidly engages the
intermediate hydraulic flow path 29. The fluid engagement is
enabled by a coupling.
The lower hydraulic flow path 20 can be a port machined into the
lower tubular body 15.
In a typical embodiment of the invention each of the hydraulic flow
paths have the same hydraulic fluid and the same flow rate.
The lower tubular body has a lower tubular body face 13. The lower
tubular body face 13 can have a flange angle ranging from 30
degrees to 90 degrees. The lower tubular body face 13 can be made
from a metal adapted to survive a highly corrosive environment.
The lower tubular portion further has a first pin 16. The pin 16
can be manufactured by Pertroquip Energy Services of Broussard La.
and Houston Tex. The first pin 16 can have a length ranging from 3
inches to 9 inches. The first pin 16 can have a cylindrical shape
and can be solid or hollow.
The first pin 16 has a first pin outer surface 17. The first pin
outer surface can be a metal, a composite, or a similar material.
The first pin outer surface 17 in a typical embodiment will be made
form the same material of the first pin 16.
In the embodiment depicted in FIG. 5, a second pin 18. The second
pin 18 concentrically surrounds the first pin 16. In the embodiment
in FIG. 5 a double pin connector is formed using the first and
second pins. The double pin connector can be adapted for multi zone
gravel packing in a hydrocarbon well. It should be noted that the
two pin embodiment is not required, and that it is possible for an
embodiment of the invention to have only a first pin 16.
FIG. 5 depicts a control line connector 46 disposed between the
first pin outer surface 17 and the lower tubular body face 13. The
control line connector 46 can be adapted to handle a fluid pressure
ranging from 2,000 psi to 20,000 psi.
FIGS. 6A and 6B depicts an embodiment of the method. The step of
forming a first half of a bottom pin connector by securing a bottom
pin connector extending hydraulic wet connector to a lower tubular
portion is depicted as step 100. The lower tubular portion can
include a lower tubular body, a first pin, and a lower hydraulic
flow path. An embodiment of the first half of a pin connector is
depicted above in FIG. 5.
The method further includes step 102 attaching the first half of
the bottom pin connector to at least one first hydraulically
operated tool. The first half of the top pin connector can be
attached to the hydraulically operated tool using a port, a quick
connect, a control line, or similar means of connecting to a
hydraulically operated tool.
In step 104 the method is depicted including attaching a first
packer with a bore to the first half of the bottom pin connector.
The packer can be attached to the first half of the bottom pin
connector by using fasteners or other removable securing means.
The first half of the bottom pin connector with the attached first
packer is run into the well downhole in step 106.
The present embodiment of the method includes forming a second half
of a bottom pin connector in step 108. The second half of the
bottom pin connector is formed by securing a bottom pin connector
receiving hydraulic wet connector to an upper tubular portion with
a seal assembly. The upper tubular portion with seal assembly is
depicted in FIG. 1 and FIG. 2.
The second half of the bottom pin connector is secured to
production tubing in step 110. The production tubing can have a
length ranging from 30 feet to 20,000 feet. A first control line
having an inside diameter ranging from 0.125 to 0.475 inches is
secured to the second half of the bottom pin connector in step
112.
In step 114 the production tubing the second half of the bottom pin
connector, and the connected first control line is run into the
well downhole. The bottom pin connector receiving hydraulic wet
connector is connected to the bottom pin connector extending
hydraulic wet connector in step 116. The bottom pin connector
receiving wet connector and the top pin connector extending
hydraulic wet connector can be quick release wet connectors.
The present embodiment of the method includes step 117, aligning
the bottom pin connector hydraulic extending wet connector and the
bottom pin connector receiving hydraulic wet connector. The
alignment can be accomplished using at least one alignment key and
one alignment groove.
The second half of the bottom pin connector is anchored to another
piece of well equipment in step 118. The anchoring can be performed
using a locking mechanism. The locking mechanism can be similar to
the one depicted in FIG. 3.
In step 120 a first half of a top pin connector is formed by
securing a second extending hydraulic wet connector to a top pin
connector lower tubular portion. The top pin connector lower
tubular portion is similar to the lower tubular portion of the
bottom pin connector.
The first half of the top pin connector is attached to at least one
second hydraulically operated tool, the second half of the bottom
pin connector, or combinations thereof in step 122. In step 124 a
second packer with a bore is attached to the first half of the top
pin connector.
In step 126 the first half of the top pin connector with the
attached second packer is ran into the well downhole.
In step 128 a second half of a top pin connector is formed by
securing a top pin connector extending hydraulic wet connector to a
top pin connector upper tubular portion. The top pin connector
upper tubular portion is similar to the bottom pin connector upper
tubular portion.
The first control line fluidly communicates with the first half of
the top pin connector, the first hydraulically operated tool, and
the second hydraulically operated tool.
A second control line is connected to the second half of the top
pin connector to for connecting to a hydraulic source in step 130.
The hydraulic source can be a hydraulic tank located on a surface,
remote from the well. The second control line is in fluid
communication with the bottom pin connector, the first
hydraulically operated tool, and the second hydraulically operated
tool, and the power source.
A second production tubing is secured to the second half of the top
pin connector in step 132. The second production tubing can be
similar to the first production tubing. In Step 134 the production
tubing with the connected second half of the top pin connector and
the connected second control line is ran into the well.
The top pin connector receiving hydraulic wet connector can be
connected to the top pin connector extending hydraulic wet
connector in step 136. The present embodiment of the method
includes step 138 aligning the top pin connector hydraulic
extending wet connector and the top pin connector receiving
hydraulic wet connector. The alignment can be accomplished using at
least one alignment key and one alignment groove.
In step 139 the second half of the top pin connector is anchored to
another piece of well equipment.
each of the upper hydraulic flow paths and intermediate hydraulic
flow paths can be sealed using a plurality of upper hydraulic flow
path seals between each tubular seal assembly body and each upper
tubular body.
A means for retaining the upper hydraulic flow path seals can be
provided. The retaining can be accomplished by using a plurality of
seal assembly fasteners.
The method can further include supporting at least one of the
hydraulic flow path seals using at least one seal ring.
The present embodiment of the method can include preventing
hydraulic fluid from escaping each of the hydraulic flow paths
using at least one hydraulic flow path plug for each pin connector
with seal assembly.
In step 140 the above steps can be repeated to adapt the method for
use with a multi-zone well having more than two zones.
The present embodiment of the invention includes step 142 which is
controlling the well, using the control lines, on a periodic basis.
The periodic basis is defined as activating the well for a time
ranging form 2 minutes to 120 minutes. The batch basis is
equivalent to the periodic basis.
The present embodiment of the method can be adapted for use with a
gravel pack using a second pin surrounding the first pin in each
lower tubular portion forming a double pin connecter.
FIG. 7 depicts an embodiment of the completion system for a well
200. The completion system for the well 200 can include an upper
production tubing 202. The upper production tubing 202 can have an
inner diameter ranging from 1.9 inches to 7 inches. The upper
production tubing 202 can be disposed in a wellbore 204. An upper
packer 206 can engage the upper production tubing 202.
The upper packer 206 can be engaged by a top pin connector with
seal assembly 210. An example of the top pin connector with seal
assembly 210 can be seen in FIGS. 1-5.
The top pin connector can engage an intermediate production tubing
212a. The intermediate production tubing 212a can be similar to the
top production tubing.
A top hydraulically operated tool 214 is depicted engaging the
intermediate production tubing 212a. The top hydraulically operated
tool 214 can be a single line sleeve, a valve, or a similar
downhole tool.
A top control line 216a is secured to a power source 218. The power
source 218 can be a remote hydraulic tank, a pressurized tank, a
fluid reservoir, or a similar fluid containment device. The upper
tubular portion of the top pin connector with seal assembly 210 is
in fluid communication with the top control line 216a.
The first intermediate production tubing 212a is secured to the
lower tubular portion of the top pin connector with seal assembly
210 and the top hydraulically operated tool 214. A second control
line 216b is connected to the lower tubular portion of the top pin
connector with seal assembly 210 and the top hydraulically operated
tool 214.
An intermediate packer 222 is depicted engaging the second
intermediate production tubing 212b.
A third control line 216c is in fluid communication from the top
hydraulically operated tool 214 to a upper tubular portion of the
intermediate pin connector with seal assembly 228. A fourth control
line 216d is in communication with the lower tubular portion of the
intermediate pin connector with seal assembly 228 and a bottom
hydraulically operated tool 229. The second bottom control line
216d can be used to periodically operate the bottom hydraulically
operated tool 229. A first bottom production tubing 212c is
disposed between the intermediate pin connector with seal assembly
and the bottom hydraulically operated tool 229.
A second bottom production tubing 212d is depicted engaging the
bottom hydraulically operated tool 229 and a lower sealing means
226. The lower sealing means 226 can be a packer, a plug, or
similar sealing means.
FIG. 8 depicts an embodiment of a completion system for a gravel
pack well 328. An upper production tubing 202 is disposed within a
wellbore 204. An upper gravel packer 207 is depicted engaging the
upper production tubing 202.
A top pin connector with seal assembly 210 is depicted engaging the
upper gravel packer 207.
The lower tubular portion of the top pin connector with seal
assembly 210 is connected to a top external blank pipe 230a; and a
top internal blank pipe 239a.
The lower portion of the top pin connector with seal assembly 210
can be connected to the top internal blank pipe 239a and the
external blank pipe 230a by a threaded connection. The top internal
blank pipe 239a can be similar to the production tubing. The top
external blank pipe 230a can be similar to the production
tubing.
A first control line 216a is connected to the upper tubular portion
of the top pin connector 210 and a power source 218. The lower
tubular portion of the top pin connector with seal assembly is
secured to a second control line 216b.
A top hydraulically operated tool 214 is connected to the top blank
pipe and is in communication with the second control line 216b
communicating with the power source 218 for periodically
controlling the top hydraulically operated tool 214.
A top well screen 232a is secured to the top external blank pipe
230a. The top well screen 232a can be slotted or ribbed.
First intermediate internal blank pipe 239b is connected to the top
hydraulically operated tool 214 and the top portion of the
intermediate pin connector with seal assembly 250. A third control
line 216c connects the top hydraulically operated tool 214 with the
upper tubular portion of the intermediate pin connector with seal
assembly 250.
A top external seal assembly 234 engages an intermediate gravel
packer 238 and a bottom of the top well screen 232a. The top
external seal assembly 234 can be a polished bore seal
assembly.
The lower portion of the intermediate pin connector with seal
assembly 250 is connected to a first intermediate external blank
pipe 230b; and a second intermediate internal blank pipe 239c.
The lower portion of the intermediate pin connector with seal
assembly 250 can be connected to the second intermediate internal
blank pipe 228c and the first intermediate external blank pipe 230b
by a threaded connection. The second Intermediate internal blank
pipe 239c can be similar to the production tubing. The first
intermediate external blank pipe 230b can be similar to the
production tubing.
The bottom hydraulically operated tool 215 is connected to a second
intermediate internal blank pipe 239c and is in communication with
a fourth control line 216d communicating with the lower tubular
portion of the intermediate pin connector 250 and the bottom
hydraulically operated tool 215.
A lower well screen 232b is secured to the first intermediate
external blank pipe 230b. The lower well screen 232b can be slotted
or ribbed. The lower well screen 232b is connected to a seal
assembly with polished bore 235, that is stung into a lower sealing
means 226.
A bottom internal blank pipe 230d is connected to the bottom
hydraulically operated tool 215 and a bottom isolation seal
assembly 242.
The embodied system is repeatable to accommodate additional
zones.
While these embodiments have been described with emphasis on the
embodiments, it should be understood that within the scope of the
appended claims, the embodiments might be practiced other than as
specifically described herein.
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